Devon Energy Reports Fourth-Quarter and Full-Year 2016 Results; Provides Updated Capital and Production Outlook
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Highlights
- Exceeded fourth-quarter production expectations
- Achieved record-setting well productivity in 2016
- Reduced operating expenses in U.S. by 42 percent from peak rates
-
Attained
$1.3 billion in annual cost savings - Delivered proved reserves growth at attractive finding costs
- Improved growth outlook driven by accelerated capital investment
“For Devon, 2016 was a transformational year,” said
“We also took important steps during the year to strengthen our
investment-grade financial position with the timely completion of our
Fourth-Quarter Production Exceeds Midpoint Guidance
Devon’s reported oil production averaged 244,000 barrels per day in the fourth quarter of 2016. With the shift to higher-margin production, oil accounted for the largest component of the company’s product mix at 45 percent of total volumes.
Total companywide production in the fourth quarter reached 537,000 oil-equivalent barrels (Boe) per day, exceeding the midpoint of guidance by 2,000 Boe per day. In an effort to maximize profitability, Devon chose to reject approximately 12,000 barrels per day of ethane in the fourth quarter.
Record-Setting Well Productivity in U.S. Resource Plays
The majority of the company’s production was attributable to its U.S.
resource plays, which averaged 396,000 Boe per day during the fourth
quarter. Production within the U.S. during 2016 benefited from drilling
activity that achieved the best new well productivity in Devon’s 45-year
history. Led by results from the STACK,
The substantial improvement in well productivity was driven by activity focused in top resource plays, improved subsurface reservoir characterization, leading-edge completion designs and improvements in lateral placement.
In
Reserve Report Highlights Operational Excellence
Devon’s estimated proved reserves were 2.1 billion Boe on
The most significant reserve growth came from the company’s U.S.
operations where proved reserves increased 7 percent to 1.6 billion Boe.
Devon’s capital programs within the U.S. added 275 million Boe of
reserves (extensions, discoveries and performance revisions) during
2016. This represents a replacement rate of approximately 175 percent
(on a retained asset basis). Excluding property acquisition costs, these
reserves were added at a finding cost of only
In
Lease Operating Costs Improve by 42 Percent in U.S. Resource Plays
Devon continued to make progress lowering operating costs in the fourth
quarter. Lease operating expenses (LOE) totaled
The company also maintained its significantly improved general and
administrative (G&A) cost structure in the fourth quarter. Including
capitalized costs, G&A expenses totaled
Cost Savings Reach
In aggregate, Devon’s cost-savings initiatives achieved
The company expects these cost savings to be sustainable in 2017 due to structural improvements and efficiency gains within its field operations and corporate support groups.
EnLink Positioned to Deliver Double-Digit Growth in 2017
Devon’s midstream business generated
In 2017, with strong growth expected from EnLink, Devon projects its
midstream operating profits will advance to a range of
Devon has a 64 percent ownership in
Fourth-Quarter 2016 Operations Report
For additional details on Devon’s E&P operations, please refer to the company’s fourth-quarter 2016 operations report at www.devonenergy.com. Highlights from the report include:
- Meramec drilling inventory increases by 40 percent
-
Leonard Shale and Delaware Sands resource potential expands - Staggered spacing tests successful in Eagle Ford
- Jackfish complex delivers record production
- Barnett cash flow generation accelerates
Divestitures and Hedging Position Enhance Strong Financial Position
On
The majority of divestiture proceeds were utilized to retire
In addition to an investment-grade balance sheet, Devon’s financial position is bolstered by a significantly increased commodity hedging position in 2017. The company currently has approximately 50 percent of its estimated oil and gas production hedged in the upcoming year and will continue to build out its hedging position in the future.
Earnings Beat Wall Street Consensus by 20 Percent
Devon’s reported net earnings totaled
The company’s significantly improved profitability in the fourth quarter
was attributable to higher commodity prices and an improved cost
structure. These factors also strengthened Devon’s operating cash flow
to
Devon Positioned to Deliver Peer-Leading Cash Flow Expansion
Detailed forward-looking guidance for the first quarter and full-year
2017 is provided later in the release. In 2017, Devon expects to further
accelerate activity in its U.S. resource plays to as many as 20 operated
rigs by year end. With this level of planned activity, the company
expects to invest between
Devon’s upstream capital plans are expected to drive 13 to 17 percent
oil production growth in the U.S. during 2017 compared to the fourth
quarter of 2016, which marks the low point of Devon’s production
profile. This resumption of growth in high-margin production will begin
in the first quarter of 2017. The operational momentum created by
accelerated drilling activity in the STACK and
Non-GAAP Reconciliations
Pursuant to regulatory disclosure requirements, Devon is required to reconcile non-GAAP (generally accepted accounting principles) financial measures to the related GAAP information. Finding cost, core earnings and core earnings per share referenced within the commentary of this release are non-GAAP financial measures. Reconciliations of these and other non-GAAP measures are provided within the tables of this release.
Conference Call Webcast and Supplemental Earnings Materials
Please note that as soon as practicable today, Devon will post an
operations report to its website at www.devonenergy.com.
The company’s fourth-quarter conference call will be held at
Forward-Looking Statements
This press release includes "forward-looking statements" as defined
by the
The
About
DEVON ENERGY CORPORATION |
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FINANCIAL AND OPERATIONAL INFORMATION |
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Quarter Ended | Year Ended | |||||||||||||||
PRODUCTION NET OF ROYALTIES | December 31, | December 31, | ||||||||||||||
2016 | 2015 | 2016 | 2015 | |||||||||||||
|
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Oil and bitumen (MBbls/d) | ||||||||||||||||
U. S. - Core | 105 | 139 | 119 | 142 | ||||||||||||
Heavy Oil | 139 | 121 | 131 | 111 | ||||||||||||
Retained assets | 244 | 260 | 250 | 253 | ||||||||||||
Divested assets | — | 18 | 10 | 22 | ||||||||||||
Total | 244 | 278 | 260 | 275 | ||||||||||||
Natural gas liquids (MBbls/d) | ||||||||||||||||
U. S. - Core | 90 | 115 | 103 | 110 | ||||||||||||
Divested assets | — | 24 | 13 | 26 | ||||||||||||
Total | 90 | 139 | 116 | 136 | ||||||||||||
Gas (MMcf/d) | ||||||||||||||||
U. S. - Core | 1,203 | 1,327 | 1,270 | 1,333 | ||||||||||||
Heavy Oil | 18 | 24 | 20 | 22 | ||||||||||||
Retained assets | 1,221 | 1,351 | 1,290 | 1,355 | ||||||||||||
Divested assets | — | 232 | 123 | 255 | ||||||||||||
Total | 1,221 | 1,583 | 1,413 | 1,610 | ||||||||||||
Oil equivalent (MBoe/d) | ||||||||||||||||
U. S. - Core | 396 | 475 | 434 | 474 | ||||||||||||
Heavy Oil | 141 | 126 | 134 | 115 | ||||||||||||
Retained assets | 537 | 601 | 568 | 589 | ||||||||||||
Divested assets | — | 80 | 43 | 91 | ||||||||||||
Total | 537 | 681 | 611 | 680 |
KEY OPERATING STATISTICS BY REGION | ||||||||||||
Quarter Ended December 31, 2016 | ||||||||||||
Avg. Production | Gross Wells | Operated Rigs at | ||||||||||
(MBoe/d) | Drilled | December 31, 2016 | ||||||||||
STACK | 88 | 55 | 6 | |||||||||
Delaware Basin | 54 | 15 | 3 | |||||||||
Eagle Ford | 60 | 29 | — | |||||||||
Heavy Oil | 141 | 12 | 3 | |||||||||
Barnett Shale | 163 | — | — | |||||||||
Rockies Oil | 15 | 11 | 1 | |||||||||
Other assets | 16 | 11 | — | |||||||||
Total | 537 | 133 | 13 | |||||||||
Year Ended December 31, 2016 | ||||||||||||
Avg. Production | Gross Wells | |||||||||||
(MBoe/d) | Drilled | |||||||||||
STACK | 93 | 133 | ||||||||||
Delaware Basin | 60 | 58 | ||||||||||
Eagle Ford | 76 | 63 | ||||||||||
Heavy Oil | 134 | 25 | ||||||||||
Barnett Shale | 169 | — | ||||||||||
Rockies Oil | 19 | 19 | ||||||||||
Other assets | 17 | 28 | ||||||||||
Retained assets | 568 | 326 | ||||||||||
Divested assets | 43 | 14 | ||||||||||
Total | 611 | 340 |
PRODUCTION TREND | 2015 | 2016 | ||||||||||||||||||
Quarter 4 | Quarter 1 | Quarter 2 | Quarter 3 | Quarter 4 | ||||||||||||||||
Oil and bitumen (MBbls/d) | ||||||||||||||||||||
STACK | 9 | 15 | 19 | 21 | 19 | |||||||||||||||
Delaware Basin | 42 | 38 | 36 | 31 | 29 | |||||||||||||||
Eagle Ford | 60 | 59 | 41 | 33 | 34 | |||||||||||||||
Heavy Oil | 121 | 126 | 121 | 137 | 139 | |||||||||||||||
Barnett Shale | 1 | 1 | 1 | 1 | 1 | |||||||||||||||
Rockies Oil | 15 | 17 | 15 | 11 | 11 | |||||||||||||||
Other assets | 12 | 12 | 11 | 11 | 11 | |||||||||||||||
Retained assets | 260 | 268 | 244 | 245 | 244 | |||||||||||||||
Divested assets | 18 | 17 | 15 | 6 | — | |||||||||||||||
Total | 278 | 285 | 259 | 251 | 244 | |||||||||||||||
Natural gas liquids (MBbls/d) | ||||||||||||||||||||
STACK | 24 | 30 | 30 | 23 | 21 | |||||||||||||||
Delaware Basin | 11 | 12 | 13 | 12 | 10 | |||||||||||||||
Eagle Ford | 27 | 24 | 17 | 13 | 11 | |||||||||||||||
Barnett Shale | 49 | 46 | 46 | 44 | 43 | |||||||||||||||
Rockies Oil | 1 | 1 | 1 | 1 | 1 | |||||||||||||||
Other assets | 3 | 2 | 3 | 3 | 4 | |||||||||||||||
Retained assets | 115 | 115 | 110 | 96 | 90 | |||||||||||||||
Divested assets | 24 | 22 | 21 | 8 | — | |||||||||||||||
Total | 139 | 137 | 131 | 104 | 90 | |||||||||||||||
Gas (MMcf/d) | ||||||||||||||||||||
STACK | 253 | 306 | 289 | 292 | 284 | |||||||||||||||
Delaware Basin | 82 | 84 | 99 | 92 | 89 | |||||||||||||||
Eagle Ford | 152 | 144 | 103 | 85 | 90 | |||||||||||||||
Heavy Oil | 24 | 15 | 28 | 18 | 18 | |||||||||||||||
Barnett Shale | 786 | 768 | 757 | 730 | 710 | |||||||||||||||
Rockies Oil | 38 | 32 | 31 | 19 | 17 | |||||||||||||||
Other assets | 16 | 17 | 14 | 13 | 13 | |||||||||||||||
Retained assets | 1,351 | 1,366 | 1,321 | 1,249 | 1,221 | |||||||||||||||
Divested assets | 232 | 215 | 206 | 75 | — | |||||||||||||||
Total | 1,583 | 1,581 | 1,527 | 1,324 | 1,221 | |||||||||||||||
Oil equivalent (MBoe/d) | ||||||||||||||||||||
STACK | 75 | 96 | 97 | 92 | 88 | |||||||||||||||
Delaware Basin | 66 | 63 | 65 | 59 | 54 | |||||||||||||||
Eagle Ford | 113 | 107 | 76 | 61 | 60 | |||||||||||||||
Heavy Oil | 126 | 129 | 126 | 140 | 141 | |||||||||||||||
Barnett Shale | 181 | 175 | 173 | 166 | 163 | |||||||||||||||
Rockies Oil | 23 | 23 | 21 | 16 | 15 | |||||||||||||||
Other assets | 17 | 18 | 16 | 16 | 16 | |||||||||||||||
Retained assets | 601 | 611 | 574 | 550 | 537 | |||||||||||||||
Divested assets | 80 | 74 | 70 | 27 | — | |||||||||||||||
Total | 681 | 685 | 644 | 577 | 537 |
BENCHMARK PRICES | ||||||||||||||||||||||||
(average prices) | Quarter 4 | December YTD | ||||||||||||||||||||||
2016 | 2015 | 2016 | 2015 | |||||||||||||||||||||
Oil ($/Bbl) - West Texas Intermediate (Cushing) | $ | 49.21 | $ | 42.15 | $ | 43.36 | $ | 48.87 | ||||||||||||||||
Natural Gas ($/Mcf) - Henry Hub | $ | 2.98 | $ | 2.27 | $ | 2.46 | $ | 2.67 | ||||||||||||||||
REALIZED PRICES | Quarter Ended December 31, 2016 | |||||||||||||||||||||||
Oil /Bitumen | NGL | Gas | Total | |||||||||||||||||||||
(Per Bbl) | (Per Bbl) | (Per Mcf) | (Per Boe) | |||||||||||||||||||||
United States | $ | 46.74 | $ | 13.81 | $ | 2.37 | $ | 22.78 | ||||||||||||||||
Canada | $ | 25.90 | N/M | N/M | $ | 25.39 | ||||||||||||||||||
Realized price without hedges | $ | 34.90 | $ | 13.81 | $ | 2.34 | $ | 23.47 | ||||||||||||||||
Cash settlements | $ | — | $ | (0.31 | ) | $ | (0.11 | ) | $ | (0.30 | ) | |||||||||||||
Realized price, including cash settlements | $ | 34.90 | $ | 13.50 | $ | 2.23 | $ | 23.17 | ||||||||||||||||
Quarter Ended December 31, 2015 | ||||||||||||||||||||||||
Oil /Bitumen | NGL | Gas | Total | |||||||||||||||||||||
(Per Bbl) | (Per Bbl) | (Per Mcf) | (Per Boe) | |||||||||||||||||||||
United States | $ | 38.04 | $ | 8.81 | $ | 1.76 | $ | 17.90 | ||||||||||||||||
Canada | $ | 18.03 | N/M |
|
N/M |
$ | 17.62 | |||||||||||||||||
Realized price without hedges | $ | 29.31 | $ | 8.81 | $ | 1.75 | $ | 17.85 | ||||||||||||||||
Cash settlements | $ | 24.36 | $ | — | $ | 0.70 | $ | 11.59 | ||||||||||||||||
Realized price, including cash settlements | $ | 53.67 | $ | 8.81 | $ | 2.45 | $ | 29.44 | ||||||||||||||||
Year Ended December 31, 2016 | ||||||||||||||||||||||||
Oil /Bitumen | NGL | Gas | Total | |||||||||||||||||||||
(Per Bbl) | (Per Bbl) | (Per Mcf) | (Per Boe) | |||||||||||||||||||||
United States | $ | 38.92 | $ | 9.81 | $ | 1.84 | $ | 18.34 | ||||||||||||||||
Canada | $ | 20.53 | N/M | N/M | $ | 20.07 | ||||||||||||||||||
Realized price without hedges | $ | 29.65 | $ | 9.81 | $ | 1.84 | $ | 18.72 | ||||||||||||||||
Cash settlements | $ | (0.43 | ) | $ | (0.11 | ) | $ | 0.07 | $ | (0.05 | ) | |||||||||||||
Realized price, including cash settlements | $ | 29.22 | $ | 9.70 | $ | 1.91 | $ | 18.67 | ||||||||||||||||
Year Ended December 31, 2015 | ||||||||||||||||||||||||
Oil /Bitumen | NGL | Gas | Total | |||||||||||||||||||||
(Per Bbl) | (Per Bbl) | (Per Mcf) | (Per Boe) | |||||||||||||||||||||
United States | $ | 44.01 | $ | 9.32 | $ | 2.17 | $ | 21.12 | ||||||||||||||||
Canada | $ | 25.14 | N/M |
|
N/M |
$ | 24.46 | |||||||||||||||||
Realized price without hedges | $ | 36.39 | $ | 9.32 | $ | 2.14 | $ | 21.68 | ||||||||||||||||
Cash settlements | $ | 20.72 | $ | — | $ | 0.57 | $ | 9.74 | ||||||||||||||||
Realized price, including cash settlements | $ | 57.11 | $ | 9.32 | $ | 2.71 | $ | 31.42 |
CONSOLIDATED STATEMENTS OF EARNINGS | ||||||||||||||||||||||||
(in millions, except per share amounts) | Quarter Ended | Year Ended | ||||||||||||||||||||||
December 31, | December 31, | |||||||||||||||||||||||
2016 | 2015 | 2016 | 2015 | |||||||||||||||||||||
Oil, gas and NGL sales | $ | 1,159 | $ | 1,118 | $ | 4,182 | $ | 5,382 | ||||||||||||||||
Oil, gas and NGL derivatives | (171 | ) | 77 | (201 | ) | 503 | ||||||||||||||||||
Marketing and midstream revenues | 1,820 | 1,691 | 6,323 | 7,260 | ||||||||||||||||||||
Asset dispositions and other | 542 | — | 1,893 | — | ||||||||||||||||||||
Total revenues and other | 3,350 | 2,886 | 12,197 | 13,145 | ||||||||||||||||||||
Lease operating expenses | 367 | 479 | 1,582 | 2,104 | ||||||||||||||||||||
Marketing and midstream operating expenses | 1,608 | 1,481 | 5,492 | 6,420 | ||||||||||||||||||||
General and administrative expenses | 163 | 194 | 645 | 855 | ||||||||||||||||||||
Production and property taxes | 55 | 73 | 275 | 388 | ||||||||||||||||||||
Depreciation, depletion and amortization | 372 | 641 | 1,792 | 3,129 | ||||||||||||||||||||
Asset impairments | 124 | 5,341 | 4,975 | 20,820 | ||||||||||||||||||||
Restructuring and transaction costs | 1 | 78 | 267 | 78 | ||||||||||||||||||||
Other operating items | 23 | 24 | 64 | 78 | ||||||||||||||||||||
Total operating expenses | 2,713 | 8,311 | 15,092 | 33,872 | ||||||||||||||||||||
Operating income (loss) | 637 | (5,425 | ) | (2,895 | ) | (20,727 | ) | |||||||||||||||||
Net financing costs | 334 | 139 | 904 | 517 | ||||||||||||||||||||
Other nonoperating items | (72 | ) | (22 | ) | 78 | 24 | ||||||||||||||||||
Earnings (loss) before income taxes | 375 | (5,542 | ) | (3,877 | ) | (21,268 | ) | |||||||||||||||||
Income tax expense (benefit) | 55 | (630 | ) | (173 | ) | (6,065 | ) | |||||||||||||||||
Net earnings (loss) | 320 | (4,912 | ) | (3,704 | ) | (15,203 | ) | |||||||||||||||||
Net earnings (loss) attributable to noncontrolling interests | (11 | ) | (380 | ) | (402 | ) | (749 | ) | ||||||||||||||||
Net earnings (loss) attributable to Devon | $ | 331 | $ | (4,532 | ) | $ | (3,302 | ) | $ | (14,454 | ) | |||||||||||||
Net earnings (loss) per share attributable to Devon: | ||||||||||||||||||||||||
Basic | $ | 0.63 | $ | (11.12 | ) | $ | (6.52 | ) | $ | (35.55 | ) | |||||||||||||
Diluted | $ | 0.63 | $ | (11.12 | ) | $ | (6.52 | ) | $ | (35.55 | ) | |||||||||||||
Weighted average common shares outstanding: | ||||||||||||||||||||||||
Basic | 524 | 413 | 513 | 412 | ||||||||||||||||||||
Diluted | 527 | 413 | 513 | 412 |
CONSOLIDATED STATEMENTS OF CASH FLOWS | ||||||||||||||||||||||||
(in millions) | ||||||||||||||||||||||||
Quarter Ended | Year Ended | |||||||||||||||||||||||
December 31, | December 31, | |||||||||||||||||||||||
2016 | 2015 | 2016 | 2015 | |||||||||||||||||||||
Cash flows from operating activities: | ||||||||||||||||||||||||
Net earnings (loss) | $ | 320 | $ | (4,912 | ) | $ | (3,704 | ) | $ | (15,203 | ) | |||||||||||||
Adjustments to reconcile net earnings (loss) to net cash
from operating activities: |
||||||||||||||||||||||||
Depreciation, depletion and amortization | 372 | 641 | 1,792 | 3,129 | ||||||||||||||||||||
Asset impairments | 124 | 5,341 | 4,975 | 20,820 | ||||||||||||||||||||
Gains and losses on asset sales | (536 | ) | — | (1,887 | ) | — | ||||||||||||||||||
Deferred income tax expense (benefit) | 27 | (480 | ) | (273 | ) | (5,828 | ) | |||||||||||||||||
Derivatives and other financial instruments | 27 | (132 | ) | 386 | (738 | ) | ||||||||||||||||||
Cash settlements on derivatives and financial instruments | (9 | ) | 775 | (142 | ) | 2,688 | ||||||||||||||||||
Asset retirement obligation accretion | 17 | 19 | 75 | 75 | ||||||||||||||||||||
Amortization of stock-based compensation | 31 | 44 | 194 | 181 | ||||||||||||||||||||
Other | 334 | 37 | 303 | 281 | ||||||||||||||||||||
Net change in working capital | (189 | ) | (404 | ) | (8 | ) | (311 | ) | ||||||||||||||||
Change in long-term other assets | 26 | 74 | 36 | 285 | ||||||||||||||||||||
Change in long-term other liabilities | (8 | ) | 68 | (1 | ) | (6 | ) | |||||||||||||||||
Net cash from operating activities | 536 | 1,071 | 1,746 | 5,373 | ||||||||||||||||||||
Cash flows from investing activities: | ||||||||||||||||||||||||
Capital expenditures | (671 | ) | (1,079 | ) | (2,330 | ) | (5,308 | ) | ||||||||||||||||
Acquisitions of property, equipment and businesses | — | (577 | ) | (1,641 | ) | (1,107 | ) | |||||||||||||||||
Divestitures of property and equipment | 1,229 | 72 | 3,118 | 107 | ||||||||||||||||||||
Other | (26 | ) | (8 | ) | (19 | ) | (16 | ) | ||||||||||||||||
Net cash from investing activities | 532 | (1,592 | ) | (872 | ) | (6,324 | ) | |||||||||||||||||
Cash flows from financing activities: | ||||||||||||||||||||||||
Borrowings of long-term debt, net of issuance costs | 483 | 1,444 | 2,145 | 4,772 | ||||||||||||||||||||
Repayments of long-term debt | (1,687 | ) | (861 | ) | (4,409 | ) | (2,634 | ) | ||||||||||||||||
Net short-term debt repayments | — | 625 | (626 | ) | (307 | ) | ||||||||||||||||||
Early retirement of debt | (183 | ) | — | (265 | ) | — | ||||||||||||||||||
Issuance of common stock | — | — | 1,469 | — | ||||||||||||||||||||
Sale of subsidiary units | — | — | — | 654 | ||||||||||||||||||||
Issuance of subsidiary units | 57 | 12 | 892 | 25 | ||||||||||||||||||||
Dividends paid on common stock | (31 | ) | (100 | ) | (221 | ) | (396 | ) | ||||||||||||||||
Contributions from noncontrolling interests | 17 | 4 | 168 | 16 | ||||||||||||||||||||
Distributions to noncontrolling interests | (80 | ) | (68 | ) | (304 | ) | (254 | ) | ||||||||||||||||
Other | (4 | ) | — | (13 | ) | (18 | ) | |||||||||||||||||
Net cash from financing activities | (1,428 | ) | 1,056 | (1,164 | ) | 1,858 | ||||||||||||||||||
Effect of exchange rate changes on cash | (66 | ) | (12 | ) | (61 | ) | (77 | ) | ||||||||||||||||
Net change in cash and cash equivalents | (426 | ) | 523 | (351 | ) | 830 | ||||||||||||||||||
Cash and cash equivalents at beginning of period | 2,385 | 1,787 | 2,310 | 1,480 | ||||||||||||||||||||
Cash and cash equivalents at end of period | $ | 1,959 | $ | 2,310 | $ | 1,959 | $ | 2,310 |
CONSOLIDATED BALANCE SHEETS | ||||||||||||
(in millions) | December 31, | December 31, | ||||||||||
2016 | 2015 | |||||||||||
Current assets: | ||||||||||||
Cash and cash equivalents | $ | 1,959 | $ | 2,310 | ||||||||
Accounts receivable | 1,356 | 1,105 | ||||||||||
Assets held for sale | 193 | — | ||||||||||
Other current assets | 264 | 606 | ||||||||||
Total current assets | 3,772 | 4,021 | ||||||||||
Property and equipment, at cost: | ||||||||||||
Oil and gas, based on full cost accounting: | ||||||||||||
Subject to amortization | 75,648 | 78,190 | ||||||||||
Not subject to amortization | 3,437 | 2,584 | ||||||||||
Total oil and gas | 79,085 | 80,774 | ||||||||||
Midstream and other | 10,455 | 10,380 | ||||||||||
Total property and equipment, at cost | 89,540 | 91,154 | ||||||||||
Less accumulated depreciation, depletion and amortization | (73,350 | ) | (72,086 | ) | ||||||||
Property and equipment, net | 16,190 | 19,068 | ||||||||||
Goodwill | 3,964 | 5,032 | ||||||||||
Other long-term assets | 1,987 | 1,330 | ||||||||||
Total assets | $ | 25,913 | $ | 29,451 | ||||||||
Current liabilities: | ||||||||||||
Accounts payable | $ | 642 | $ | 906 | ||||||||
Revenues and royalties payable | 908 | 763 | ||||||||||
Short-term debt | — | 976 | ||||||||||
Other current liabilities | 1,066 | 650 | ||||||||||
Total current liabilities | 2,616 | 3,295 | ||||||||||
Long-term debt | 10,154 | 12,056 | ||||||||||
Asset retirement obligations | 1,226 | 1,370 | ||||||||||
Other long-term liabilities | 894 | 853 | ||||||||||
Deferred income taxes | 648 | 888 | ||||||||||
Stockholders’ equity: | ||||||||||||
Common stock | 52 | 42 | ||||||||||
Additional paid-in capital | 7,237 | 4,996 | ||||||||||
Retained earnings (accumulated deficit) | (1,646 | ) | 1,781 | |||||||||
Accumulated other comprehensive earnings | 284 | 230 | ||||||||||
Total stockholders’ equity attributable to Devon | 5,927 | 7,049 | ||||||||||
Noncontrolling interests | 4,448 | 3,940 | ||||||||||
Total stockholders’ equity | 10,375 | 10,989 | ||||||||||
Total liabilities and stockholders’ equity | $ | 25,913 | $ | 29,451 | ||||||||
Common shares outstanding | 523 | 418 |
CONSOLIDATING STATEMENTS OF OPERATIONS | ||||||||||||||||||||||||
(in millions) | ||||||||||||||||||||||||
Quarter Ended December 31, 2016 | ||||||||||||||||||||||||
Devon U.S. |
EnLink | Eliminations | Total | |||||||||||||||||||||
Oil, gas and NGL sales | $ | 1,159 | $ | — | $ | — | $ | 1,159 | ||||||||||||||||
Oil, gas and NGL derivatives | (171 | ) | — | — | (171 | ) | ||||||||||||||||||
Marketing and midstream revenues | 758 | 1,225 | (163 | ) | 1,820 | |||||||||||||||||||
Asset dispositions and other | 558 | (16 | ) | — | 542 | |||||||||||||||||||
Total revenues and other | 2,304 | 1,209 | (163 | ) | 3,350 | |||||||||||||||||||
Lease operating expenses | 367 | — | — | 367 | ||||||||||||||||||||
Marketing and midstream operating expenses | 769 | 1,002 | (163 | ) | 1,608 | |||||||||||||||||||
General and administrative expenses | 133 | 30 | — | 163 | ||||||||||||||||||||
Production and property taxes | 48 | 7 | — | 55 | ||||||||||||||||||||
Depreciation, depletion and amortization | 241 | 131 | — | 372 | ||||||||||||||||||||
Asset impairments | 124 | — | — | 124 | ||||||||||||||||||||
Restructuring and transaction costs | 1 | — | — | 1 | ||||||||||||||||||||
Other operating items | 23 | — | — | 23 | ||||||||||||||||||||
Total operating expenses | 1,706 | 1,170 | (163 | ) | 2,713 | |||||||||||||||||||
Operating income | 598 | 39 | — | 637 | ||||||||||||||||||||
Net financing costs | 284 | 50 | — | 334 | ||||||||||||||||||||
Other nonoperating items | (92 | ) | 20 | — | (72 | ) | ||||||||||||||||||
Earnings (loss) before income taxes | 406 | (31 | ) | — | 375 | |||||||||||||||||||
Income tax expense (benefit) | 56 | (1 | ) | — | 55 | |||||||||||||||||||
Net earnings (loss) | 350 | (30 | ) | — | 320 | |||||||||||||||||||
Net loss attributable to noncontrolling interests | — | (11 | ) | — | (11 | ) | ||||||||||||||||||
Net earnings (loss) attributable to Devon | $ | 350 | $ | (19 | ) | $ | — | $ | 331 |
OTHER KEY STATISTICS |
|||||||||||||||||||||||
(in millions) | Quarter Ended December 31, 2016 | ||||||||||||||||||||||
Devon U.S. |
EnLink | Eliminations | Total | ||||||||||||||||||||
Cash flow statement related items: | |||||||||||||||||||||||
Operating cash flow | $ | 383 | $ | 153 | $ | — | $ | 536 | |||||||||||||||
Capital expenditures | $ | (432 | ) | $ | (239 | ) | $ | — | $ | (671 | ) | ||||||||||||
Divestitures of property and equipment | $ | 1,141 | $ | 88 | $ | — | $ | 1,229 | |||||||||||||||
Repayments of long-term debt | $ | (1,254 | ) | $ | (433 | ) | $ | — | $ | (1,687 | ) | ||||||||||||
EnLink distributions received (paid) | $ | 66 | $ | (146 | ) | $ | — | $ | (80 | ) | |||||||||||||
Issuance of subsidiary units | $ | — | $ | 57 | $ | — | $ | 57 | |||||||||||||||
Balance sheet statement items: | |||||||||||||||||||||||
Net debt (1) | $ | 4,911 | $ | 3,284 | $ | — | $ | 8,195 | |||||||||||||||
(1) Net debt is a non-GAAP measure. For a reconciliation of the comparable GAAP measure, see "Non-GAAP Financial Measures" later in this release. |
CAPITAL EXPENDITURES | ||||||||||
(in millions) | ||||||||||
Quarter Ended December 31, 2016 | Year Ended December 31, 2016 | |||||||||
Exploration and development capital(1) | $ | 363 | $ | 1,166 | ||||||
Capitalized G&A and interest | 78 | 308 | ||||||||
Acquisitions | 36 | 1,595 | ||||||||
Other | 20 | 40 | ||||||||
Devon capital expenditures(2) | $ | 497 | $ | 3,109 | ||||||
(1) Exploration and development capital in this table is presented before capitalized G&A and interest. The full-year amount excludes a $95 million positive revision to future asset retirement obligations, which is included in costs incurred. The fourth quarter and full-year amounts include $8 million and $32 million for abandonment expenditures paid during each respective period, which are not included in costs incurred. |
(2) Excludes $266 and $1,082 million attributable to EnLink for the fourth quarter and year end of 2016, respectively. |
COSTS INCURRED | Total | |||||||||
(in millions) | Year Ended December 31, | |||||||||
2016 | 2015 | |||||||||
Property acquisition costs: | ||||||||||
Proved properties | $ | 237 | $ | 195 | ||||||
Unproved properties | 1,358 | 717 | ||||||||
Exploration costs | 394 | 587 | ||||||||
Development costs | 1,143 | 3,671 | ||||||||
Costs Incurred | $ | 3,132 | $ | 5,170 | ||||||
United States | ||||||||||
Year Ended December 31, | ||||||||||
2016 | 2015 | |||||||||
Property acquisition costs: | ||||||||||
Proved properties | $ | 237 | $ | 193 | ||||||
Unproved properties | 1,356 | 634 | ||||||||
Exploration costs | 345 | 478 | ||||||||
Development costs | 1,034 | 3,269 | ||||||||
Costs Incurred | $ | 2,972 | $ | 4,574 | ||||||
Canada | ||||||||||
Year Ended December 31, | ||||||||||
2016 | 2015 | |||||||||
Property acquisition costs: | ||||||||||
Proved properties | $ | — | $ | 2 | ||||||
Unproved properties | 2 | 83 | ||||||||
Exploration costs | 49 | 109 | ||||||||
Development costs | 109 | 402 | ||||||||
Costs Incurred | $ | 160 | $ | 596 |
RESERVES RECONCILIATION | ||||||||||||||||||||
Total | ||||||||||||||||||||
Oil / Bitumen |
Gas |
NGL |
Total |
|||||||||||||||||
As of December 31, 2015: | ||||||||||||||||||||
Proved developed | 444 | 5,707 | 411 | 1,806 | ||||||||||||||||
Proved undeveloped | 340 | 114 | 17 | 376 | ||||||||||||||||
Total Proved | 784 | 5,821 | 428 | 2,182 | ||||||||||||||||
Revisions due to prices | 3 | (103 | ) | (13 | ) | (27 | ) | |||||||||||||
Revisions other than price | (18 | ) | 638 | 48 | 137 | |||||||||||||||
Extensions and discoveries | 38 | 280 | 42 | 126 | ||||||||||||||||
Purchase of reserves | 8 | 33 | 7 | 20 | ||||||||||||||||
Production | (95 | ) | (517 | ) | (42 | ) | (223 | ) | ||||||||||||
Sale of reserves | (25 | ) | (521 | ) | (45 | ) | (157 | ) | ||||||||||||
As of December 31, 2016: | ||||||||||||||||||||
Proved developed | 367 | 5,377 | 387 | 1,649 | ||||||||||||||||
Proved undeveloped | 328 | 254 | 38 | 409 | ||||||||||||||||
Total Proved | 695 | 5,631 | 425 | 2,058 | ||||||||||||||||
United States | ||||||||||||||||||||
Oil / Bitumen |
Gas |
NGL |
Total |
|||||||||||||||||
As of December 31, 2015: | ||||||||||||||||||||
Proved developed | 203 | 5,694 | 411 | 1,563 | ||||||||||||||||
Proved undeveloped | 39 | 114 | 17 | 75 | ||||||||||||||||
Total Proved | 242 | 5,808 | 428 | 1,638 | ||||||||||||||||
Revisions due to prices | (18 | ) | (103 | ) | (13 | ) | (48 | ) | ||||||||||||
Revisions other than price | (2 | ) | 628 | 48 | 151 | |||||||||||||||
Extensions and discoveries | 36 | 280 | 42 | 124 | ||||||||||||||||
Purchase of reserves | 8 | 33 | 7 | 20 | ||||||||||||||||
Production | (47 | ) | (510 | ) | (42 | ) | (174 | ) | ||||||||||||
Sale of reserves | (25 | ) | (521 | ) | (45 | ) | (157 | ) | ||||||||||||
As of December 31, 2016: | ||||||||||||||||||||
Proved developed | 160 | 5,361 | 387 | 1,439 | ||||||||||||||||
Proved undeveloped | 34 | 254 | 38 | 115 | ||||||||||||||||
Total Proved | 194 | 5,615 | 425 | 1,554 | ||||||||||||||||
Canada | ||||||||||||||||||||
Oil / Bitumen |
Gas |
NGL |
Total |
|||||||||||||||||
As of December 31, 2015: | ||||||||||||||||||||
Proved developed | 241 | 13 | — | 243 | ||||||||||||||||
Proved undeveloped | 301 | — | — | 301 | ||||||||||||||||
Total Proved | 542 | 13 | — | 544 | ||||||||||||||||
Revisions due to prices | 21 | — | — | 21 | ||||||||||||||||
Revisions other than price | (16 | ) | 10 | — | (14 | ) | ||||||||||||||
Extensions and discoveries | 2 | — | — | 2 | ||||||||||||||||
Production | (48 | ) | (7 | ) | — | (49 | ) | |||||||||||||
As of December 31, 2016: | ||||||||||||||||||||
Proved developed | 207 | 16 | — | 210 | ||||||||||||||||
Proved undeveloped | 294 | — | — | 294 | ||||||||||||||||
Total Proved | 501 | 16 | — | 504 | ||||||||||||||||
NON-GAAP FINANCIAL MEASURES
This press release includes non-GAAP financial measures. These non-GAAP measures are not alternatives to GAAP measures, and you should not consider these non-GAAP measures in isolation or as a substitute for analysis of our results as reported under GAAP. Below is additional disclosure regarding each of the non-GAAP measures used in this press release, including reconciliations to their most directly comparable GAAP measure.
CORE EARNINGS
Devon’s reported net earnings include items of income and expense that are typically excluded by securities analysts in their published estimates of the company’s financial results. Accordingly, the company also uses the measures of core earnings and core earnings per share attributable to Devon. Devon believes these non-GAAP measures facilitate comparisons of its performance to earnings estimates published by securities analysts. Devon also believes these non-GAAP measures can facilitate comparisons of its performance between periods and to the performance of its peers. The following table summarizes the effects of these items on fourth-quarter 2016 earnings.
(in millions, except per share amounts) | Quarter Ended December 31, 2016 | |||||||||||||||||||||||
Before-tax | After-tax |
After |
Per Share | |||||||||||||||||||||
Earnings attributable to Devon (GAAP) | $ | 375 | $ | 320 | $ | 331 | $ | 0.63 | ||||||||||||||||
Adjustments: | ||||||||||||||||||||||||
Gains and losses on asset sales | (539 | ) | (455 | ) | (462 | ) | (0.87 | ) | ||||||||||||||||
Asset impairments | 145 | 107 | 100 | 0.19 | ||||||||||||||||||||
Deferred tax asset valuation allowance | — | (16 | ) | (16 | ) | (0.03 | ) | |||||||||||||||||
Restructuring and transaction costs | 1 | 1 | 1 | — | ||||||||||||||||||||
Fair value changes in financial instruments and foreign currency | 69 | 62 | 59 | 0.11 | ||||||||||||||||||||
Early retirement of debt | 185 | 118 | 118 | 0.22 | ||||||||||||||||||||
Core earnings attributable to Devon (Non-GAAP) | $ | 236 | $ | 137 | $ | 131 | $ | 0.25 | ||||||||||||||||
NET DEBT
Devon defines net debt as debt less cash and cash equivalents and net debt attributable to the consolidation of EnLink Midstream as presented in the following table. Devon believes that netting these sources of cash against debt and adjusting for EnLink net debt provides a clearer picture of the future demands on cash from Devon to repay debt.
(in millions) | December 31, 2016 | |||||||||||||||||
Devon U.S. & Canada | EnLink | Devon Consolidated | ||||||||||||||||
Total debt (GAAP) | $ | 6,859 | $ | 3,295 | $ | 10,154 | ||||||||||||
Less cash and cash equivalents | (1,948 | ) | (11 | ) | (1,959 | ) | ||||||||||||
Net debt (Non-GAAP) | $ | 4,911 | $ | 3,284 | $ | 8,195 | ||||||||||||
FINDING COST
Finding cost is defined as costs incurred less acquisitions costs. Devon believes finding cost is relevant because it provides additional insight into costs associated with current year exploration and development activities. Certain securities analysts also use this methodology to measure Devon’s performance. It should be noted that the actual costs of reserves added through Devon’s drilling program will differ, sometimes significantly, from the direct comparison of capital spent and reserves added in any given period due to the timing of capital expenditures and reserves bookings.
(in millions) | Year Ended December 31, 2016 | ||||
United States | |||||
Costs Incurred (GAAP) | $ | 2,972 | |||
Less: | |||||
Acquisition costs | 1,593 | ||||
Finding cost (Non-GAAP) | $ | 1,379 | |||
Revisions other than price | 151 | ||||
Extensions and discoveries | 124 | ||||
Total | 275 | ||||
Finding cost per BOE (Non-GAAP) | $ | 5.01 | |||
UPSTREAM CASH FLOW
Devon defines upstream cash flow as cash flow from operations less EnLink cash flow from operations, less cash flow from divested assets and debt repayments, plus distributions received from EnLink. Devon believes upstream cash flow is relevant because it provides a clearer picture of cash flow generation ability from Devon’s retained upstream assets and its investment in EnLink.
(in millions) | |||||
Year Ended December 31, 2016 | |||||
Consolidated cash flow from operations (GAAP) | $ | 1,746 | |||
Less: EnLink cash flow from operations | 666 | ||||
Devon cash flow from operations | 1,080 | ||||
Less: cash flow from divested assets | 150 | ||||
Less: cash associated with debt repayments | 265 | ||||
Add: EnLink distributions received | 265 | ||||
Upstream cash flow (Non-GAAP) | $ | 930 | |||
DEVON ENERGY CORPORATION |
||||||||||||||||
FORWARD-LOOKING GUIDANCE |
||||||||||||||||
PRODUCTION GUIDANCE | Quarter 1 | Full Year | ||||||||||||||
Low | High | Low | High | |||||||||||||
Oil and bitumen (MBbls/d) | ||||||||||||||||
U.S. | 114 | 118 | 119 | 123 | ||||||||||||
Heavy Oil | 133 | 138 | 130 | 135 | ||||||||||||
Total | 247 | 256 | 249 | 258 | ||||||||||||
Natural gas liquids (MBbls/d) | ||||||||||||||||
Total | 88 | 93 | 95 | 100 | ||||||||||||
Gas (MMcf/d) | ||||||||||||||||
U.S. | 1,190 | 1,220 | 1,160 | 1,200 | ||||||||||||
Heavy Oil | 14 | 18 | 14 | 16 | ||||||||||||
Total | 1,204 | 1,238 | 1,174 | 1,216 | ||||||||||||
Oil equivalent (MBoe/d) | ||||||||||||||||
U.S. | 400 | 414 | 407 | 423 | ||||||||||||
Heavy Oil | 135 | 141 | 132 | 138 | ||||||||||||
Total | 535 | 555 | 539 | 561 |
PRICE REALIZATIONS GUIDANCE | Quarter 1 | Full Year | ||||||||||||||||||||||
Low | High | Low | High | |||||||||||||||||||||
Oil and bitumen - % of WTI | ||||||||||||||||||||||||
U.S. | 88 | % | 98 | % | 88 | % | 98 | % | ||||||||||||||||
Canada | 45 | % | 55 | % | 48 | % | 58 | % | ||||||||||||||||
NGL - realized price | $ | 12 | $ | 15 | $ | 12 | $ | 15 | ||||||||||||||||
Natural gas - % of Henry Hub | 78 | % | 88 | % | 78 | % | 88 | % |
OTHER GUIDANCE ITEMS | Quarter 1 | Full Year | ||||||||||||||||||||||
($ millions, except %) | Low | High | Low | High | ||||||||||||||||||||
Marketing & midstream operating profit | $ | 200 | $ | 220 | $ | 900 | $ | 950 | ||||||||||||||||
Lease operating expenses | $ | 350 | $ | 400 | $ | 1,500 | $ | 1,600 | ||||||||||||||||
General & administrative expenses - Devon | $ | 130 | $ | 150 | $ | 500 | $ | 550 | ||||||||||||||||
General & administrative expenses - EnLink | $ | 35 | $ | 45 | $ | 130 | $ | 140 | ||||||||||||||||
Production and property taxes | $ | 75 | $ | 85 | $ | 275 | $ | 325 | ||||||||||||||||
Depreciation, depletion and amortization | $ | 375 | $ | 425 | $ | 1,650 | $ | 1,750 | ||||||||||||||||
Other operating items | $ | 15 | $ | 25 | $ | 70 | $ | 80 | ||||||||||||||||
Net financing costs | $ | 125 | $ | 135 | $ | 485 | $ | 535 | ||||||||||||||||
Current income tax rate | 5.0 | % | 15.0 | % | 5.0 | % | 15.0 | % | ||||||||||||||||
Deferred income tax rate | 20.0 | % | 30.0 | % | 20.0 | % | 30.0 | % | ||||||||||||||||
Total income tax rate | 25.0 | % | 45.0 | % | 25.0 | % | 45.0 | % | ||||||||||||||||
Net earnings attributable to noncontrolling interests | $ | — | $ | 5 | $ | 50 | $ | 100 |
CAPITAL EXPENDITURES GUIDANCE | Quarter 1 | Full Year | ||||||||||||||||||
(in millions) | Low | High | Low | High | ||||||||||||||||
Exploration and development | $ | 450 | $ | 500 | $ | 2,000 | $ | 2,300 | ||||||||||||
Capitalized G&A | 55 | 65 | 200 | 250 | ||||||||||||||||
Capitalized interest | 15 | 20 | 60 | 90 | ||||||||||||||||
Other | 5 | 10 | 25 | 50 | ||||||||||||||||
Devon capital expenditures (1) | $ | 525 | $ | 595 | $ | 2,285 | $ | 2,690 | ||||||||||||
(1) Excludes capital expenditures related to EnLink. |
COMMODITY HEDGES | |||||||||||||||||||||||
Oil Commodity Hedges | |||||||||||||||||||||||
Price Swaps | Price Collars | ||||||||||||||||||||||
Period | Volume (Bbls/d) |
Weighted |
Volume |
Weighted |
Weighted |
||||||||||||||||||
Q1-Q4 2017 | 73,760 | $ | 54.33 | 56,259 | $ | 45.45 | $ | 58.11 | |||||||||||||||
Q1-Q4 2018 | 4,096 | $ | 54.31 | 7,685 | $ | 47.77 | $ | 57.77 |
Oil Basis Swaps | ||||||||||||||
Period | Index | Volume (Bbls/d) |
Weighted Average Differential to |
|||||||||||
Q1-Q4 2017 | Western Canadian Select | 26,910 | $ | (15.24 | ) | |||||||||
Q1-Q4 2017 | Midland Sweet | 17,534 | $ | (0.41 | ) |
Natural Gas Commodity Hedges | |||||||||||||
Price Swaps | Price Collars | ||||||||||||
Period |
Volume |
Weighted |
Volume |
Weighted |
Weighted |
||||||||
Q1-Q4 2017 | 209,863 | $ | 3.16 | 360,425 | $ | 2.99 | $ | 3.40 | |||||
Q1-Q4 2018 | 44,500 | $ | 3.32 | 33,904 | $ | 3.29 | $ | 3.64 | |||||
Devon’s oil derivatives settle against the average of the prompt month
NYMEX West Texas Intermediate futures price. Devon’s natural gas
derivatives settle against the Inside FERC first of the month Henry Hub
index. Commodity hedge positions are shown as of
View source version on businesswire.com: http://www.businesswire.com/news/home/20170214006351/en/
Source:
Devon Energy Corporation
Investor Contacts
Scott Coody,
405-552-4735
Chris Carr, 405-228-2496
Media Contact
John
Porretto, 405-228-7506